Det norske oljeselskap ASA has interests in four fields in production (Category 1):
The company's assessments of the remaining reserves in these fields are based on the operators' evaluations.
The Varg Field (PL 038) is located south of Sleipner Ost. The field is developed with the production vessel “Petrojarl Varg” with integrated oil storage, and a connected wellhead platform. Oil is exported using shuttle tankers. Two new wells were completed in 2008, proving up new reserves and increasing the total production to around 14,000 bopd. Proved reserves (1P/P90) include reserves with an accumulated probability of 90 % from existing wells, assuming no new wells are being drilled. Remaining proved plus probable reserves (2P/P50) are based on production cut-off in 2012 and contain the total volumes from the base case production profile provided by the operator, assuming no infill drilling. Total ultimate recoverable reserves are estimated at 95 million barrels of oil, while total remaining proved and probable reserves are estimated at 16.5 million barrels, hereof 9.4 million barrels developed. The 7 million barrels of undeveloped reserves are associated with planned wells in 2010 and onward. The reserves reflect a longer production time than earlier reported due to an extended lease period with the FPSO owner.
The Glitne Field (PL 048 B) is located 40 kilometers northeast of the Sleipner area. The field is produced by subsea wells tied to the production vessel "Petrojarl 1," and oil is exported using shuttle tankers. Total reserves are determined by the operator based on decline analysis combined with reservoir simulation and with a production cut-off in 2010. The main uncertainty in future production is the water cut development in individual wells. Remaining reserves are assessed probabilistically considering relevant uncertainties related to the
The Enoch Field (PL 048B) straddles the Norwegian/UK border and is located in the UK block 16/13a and in the Norwegian block 15/5 southwest of the Glitne Field. The field is developed by a single, horizontal subsea well and tied back to the UK Brae A platform where the oil is processed and exported via the Forties pipeline network. The gas is sold to Brae. Production started in May 2007. The field has been unitized with the license owners in British sector, and Det norske’s overall share is 2% (10% of the Norwegian license PL 048 D). Total initial proved plus probable reserves (Enoch Unit) are estimated by the operator at 15 million barrels of oil equivalents of which 10.2 million barrels remain.
The Jotun Field (PL 027 B, PL 103) is developed with an integrated well head platform (Jotun B) of 24 well slots and a FPSO (Jotun A) with three stage separation. Oil is shuttled to the Slagen refinery and gas is exported into Statpipe. Proved reserves (2P/P50) include expected volume from existing wells, assuming no new wells are being drilled and abandonment of the field in 2015. Total reserves are determined by the operator based on decline analysis combined with reservoir simulation. The main uncertainty in future production is the water cut development in individual wells. Total initial recoverable reserves are estimated at 148 million barrels of oil. Total remaining proved and probable reserves are estimated at 11.41 million barrels oil and classified as "Developed assets."
Det norske's share of production from the Varg, Glitne, Enoch, and Jotun fields during 2008 amounts to 0.66 million barrels of oil equivalents.
The Froy Field (PL 364) is operated by Det norske (50%) with Premier Norge AS as a partner. A PDO was submitted to the authorities in September 2008 and subsequently committed by both Det norske and the partner Premier Norge AS. OED has granted an extension of the license for 10 years until 2019. The field was in production from 1995 to 2001 and produced 35 million barrels with Elf as operator. Based on a comprehensive evaluation of the reservoir and production history, the best estimate is that the recovery factor can be increased from the original 18 % to minimum 40 %, increasing recovered volumes by 56 million barrels. The reserves are classified as "Development decided."
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